Conductor pipe string deflector and method of using same

ABSTRACT

An apparatus for deflecting a tubular string preferably comprising at least one side nozzle near the lower end of a first tubular string. The nozzle permits passage of a fluid therethrough from the first tubular string bore and deflects the first tubular string in a substantially horizontal direction. A second tubular string may be lowered over the deflected first tubular string. The second tubular string and the first tubular string are preferably lowered into the sea floor for maintaining their deflection. A method for deflecting a first tubular string and securing the first tubular string in the deflected state preferably comprises lowering the first tubular string axially so that the lower end of the first tubular string is near the sea floor. Preferably, a fluid, such as seawater, is propelled down through the bore of the first tubular string and through at least one side nozzle near the lower end of the first tubular, wherein the fluid moving through the side nozzle deflects the first tubular string. The first tubular string end is preferably lowered into the sea floor for maintaining the deflection of the first tubular string. A second tubular string may then be slidably lowered over the first tubular string for deflecting the second tubular string.

RELATED APPLICATION

This application relates to U.S. patent application Ser. No. ______,filed ______, for Conductor Pipe String Deflector and Method.

FIELD OF THE INVENTION

This invention pertains to apparatus and method for the deflection of atubular string which may be suspended from a drilling or service rig orplatform.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 illustrates a side elevated view of the lower portion of anoffshore installation utilizing the deflector apparatus according to thepresent invention;

FIG. 2 illustrates a side elevated, diagrammatic view of a prior artsystem involving a selected portion of the installation of theembodiment illustrated in FIG. 1 with a diver and winch line in useintending to be used to be used to laterally shift the upper portion ofa separated tubular string;

FIG. 3 illustrates a side elevated view of an alternative prior artsystem involving a whipstock that has been speared into an abandonedwell pipe;

FIG. 4 illustrates a cross-sectional elevated side view of a deflectorsub according to the present invention;

FIG. 5 illustrates an exploded, elevated perspective view of analternative embodiment of a deflector sub according to the presentinvention;

FIG. 6 illustrates a longitudinal, cross-sectional view of theembodiment illustrated in FIG. 5 according to the present invention;

FIG. 6A illustrates an end plan view of the embodiment illustrated inFIG. 6 according to the present invention;

FIG. 6B illustrates an enlarged, detail view, partly in cross section ofthe nozzle-receiving portion of the deflector sub body illustrated inFIG. 6A according to the present invention;

FIG. 7 illustrates a side view, partially cut away, of an alternativeembodiment of the deflector sub according to the present invention;

FIG. 8 illustrates a side elevated, diagrammatic view of a tubularstring deflected by a fluid jet according to the present invention;

FIG. 9 illustrates a side elevated, diagrammatic view of the embodimentillustrated in FIG. 8 further illustrating a second tubular beinglowered over a deflected tubular string according to the presentinvention;

FIG. 10 illustrates a side elevated, diagrammatic view of a pair ofconcentric tubulars being pushed into the seabed according to thepresent invention;

FIG. 11 illustrates a side elevated view of the internal tubular stringillustrated in FIG. 10 having been removed according to the presentinvention;

FIG. 12 illustrates a side elevated view of an alternative embodimentwith the exterior tubular illustrated in FIG. 10 being in place duringthe deflection process according to the present invention;

FIG. 13 illustrates a side cut away, elevated view of a jet nozzleswitching apparatus, with a piston in a first position, according to thepresent invention;

FIG. 14 illustrates a side cut away, elevated view of an alternativeembodiment with a drop ball in place, with a piston in a first position,according to the present invention;

FIG. 15 illustrates a side cut away, elevated view of the embodimentillustrated in FIG. 13 with the piston in a second position according tothe present invention;

FIG. 16 illustrates a side cut away, elevated view of the embodimentillustrated in FIG. 15 with the drop ball expelled according to thepresent invention;

FIG. 17 illustrates a side cut away, elevated view of the embodimentillustrated in FIG. 16 further illustrating a removal tool according tothe present invention;

FIG. 18 illustrates a side cut away, elevated view of the embodimentillustrated in FIG. 17 with the nozzle switching apparatus removedaccording to the present invention;

FIG. 19 illustrates an elevated, pictorial view of a drive shoeaccording to the present invention;

FIG. 20 is a partial, elevated view of an alternative embodiment of theinvention in which a nozzle is used in the side wall of a conductorpipe, thereby allowing the conductor pipe to be directly deflected; and

FIG. 21 is a graphic illustration showing the resulting deflection of atubular which is opposite from the vector sum of the thrusts generatedin accordance with the invention.

DETAILED DESCRIPTION OF EMBODIMENTS

It should be understood that the description herein below may use theterms drill string, pipe string, or the more general term tubular ortubular string interchangeably without intention of limitation. Itshould be further understood that the device and method described hereincan be applied to tubulars other than drill string, casing, or tubing.

FIG. 1 illustrates the lower portion of a typical fixed offshoreplatform 1. It is well known in the art that the platform structurestands in the seabed B, is preferably anchored in a conventional manner,and preferably has vertically distributed braces such as illustrated bybraces 1 a-1 d. It is further well known that the platform comprises aplurality of “slots” through which one or more wells can be drilled.Typically, guide sleeves 15 are mounted to the braces 1 a-1 d and aresubstantially vertically aligned with the “slots”. Typically, tubulars,used for drilling and production operations are lowered through the“slots” and the corresponding vertically aligned guide sleeves 15. Suchslots and guide sleeves are conventional and well known in this art.

It is well known that due to size constraints of the platform 1, thenumber of “slots” is limited. It is further known that if a wellbore,which corresponds to a particular “slot” and its vertically alignedguide sleeves 15 becomes unuseable, that “slot” also becomes unuseableunless the tubular string, which is to be lowered through the unuseable“slot” can be deflected, from a substantially vertical position, inorder to position a new wellbore proximate the unuseable wellbore. It isstill further well known, in the art, that a wellbore becomes unuseablefor a variety of reasons, including but not limited to, stuck tubularsor tools, adverse borehole conditions, and the like. Typically, in anunuseable wellbore, the tubulars are cut off below the mudline and areabandoned for the purposes of the drilling and/or production operations.Typically, after the unuseable wellbore is abandoned, all tubulars areremoved from the corresponding “slot” and its vertically aligned guidesleeves 15. Therefore, the “slot” is only unuseable from the point ofview of utilizing a substantially vertical tubular string.

Still referring to FIG. 1, when a “slot” is to be recovered, a newtubular string 2 is lowered through the particular “slot” and must bedeflected, in a substantially horizontal direction, to bypass theunuseable wellbore. According to the present apparatus, this deflectionis preferably accomplished by utilizing a jet sub 3 b as furtherdescribed herein below.

FIGS. 2 and 3 illustrate a pair of prior art systems for attempting thetubular string deflection necessary for the “slot” recovery. FIG. 2illustrates the use of a diver 4B to secure a winch line or cable 4 a tothe platform 1 in an attempt to deflect a pipe 5 in a substantiallyhorizontal direction. A pulley 4 is secured to the platform 1. Line 4 ahooks around the pipe 5 and pulley 4 and leads to the surface and awinch on the platform. However, this method for deflecting a pipe stringpresents several problems including the fact that underwater divingoperations are inherently risky and weather conditions must beacceptable for divers to operate. Therefore, the procedure is oftensuspended during inclement weather conditions causing unpredictabledelays to the offshore operations.

FIG. 3 illustrates using a whipstock 6 which is typically speared intothe top of an existing pipe EP that has been cut off below the mud line.The whipstock wedge surface or trough 6 b serves to guide and deflectthe descending pipe string 5 horizontally. However, this method fordeflecting a pipe string also presents several problems includingdifficulty in stabbing the whipstock into the existing pipe and theprobability that the whipstock will become stuck in the mud andprematurely be set and separate from the tubular string.

FIGS. 4-7 illustrate embodiments of the deflector sub 3 b, according tothe present invention. FIG. 4 illustrates the basic structure andoperation of the deflector sub 3 b. Preferably, the deflector sub 3 bhas a closed end 19. However, it should be appreciated that thedeflector sub 3 b does not have to be positioned at the lowermost end ofthe tubular string 3, illustrated in FIG. 1. The deflector sub 3 b maybe positioned uphole or behind additional subs or devices (FIG. 7). Itshould be further appreciated that the deflector sub 3 may comprisevarious top and bottom connections, such as, but not limited to, box andpin connections respectively, and as such, the closed end 19 may be aseparate structure attached to the deflector sub 3 b by threadedattachment, welding, or any other means of conventional attachment ormay be located downhole of the deflector sub 3 b.

Preferably, pumps, or other fluid driving devices, such as the rig pumpsmay push or propel seawater or other fluid into the tubular string 3 inthe general direction indicated by the arrow 17. The selection of thefluid, being pumped into the tubular string 3 may be dependent on theenvironment, particularly the environment into which the fluid will bedischarged. Preferably, the seawater, or other fluid, is pumped throughthe tubular string 3 and into the deflector sub 3 b.

Preferably a jet nozzle 3 b 2 is positioned in the sidewall of thedeflector sub 3 b and becomes the outlet for the seawater or other fluidbeing pumped through the deflector sub 3 b. As the fluid exits throughthe nozzle 3 b 2 it will produce a fluid jet 3 b 1. The fluid jet 3 b 1,in turn, preferably produces a thrust 3 b 3, in a substantially oppositedirection from the fluid jet 3 b 1 and thus moves the deflector sub inthe direction of the thrust 3 b 3. It should be appreciated that theamount of pressure in the bore of the tubular string 3 and the nozzle 3b 2 size influences the amount of the thrust force 3 b 3, which in turnsubstantially determines the amount of deflection of the tubular string3. It should be appreciated, by those skilled in the art, that nozzle 3b 2 is typically a commercially available item and can be found in avariety of sizes. However, the utilization of non-commercial ornon-conventional nozzle sizes should not be viewed as a limitation ofthe present apparatus or method.

FIG. 5 illustrates further detail of the deflector sub 3 b whichpreferably comprises a deflector sub body 16, nozzle 3 b 2, O-ring 18,and retaining ring 20. It should be appreciated that nozzle 3 b 2,O-ring 18, and retaining ring 20, whether commercially available orspecifically manufactured for a particular application, are well knownin the art and will not be described in detail herein. FIGS. 6 and 6Aillustrate cross-sectional, longitudinal and end views, respectively, ofdeflector sub body 16. Orifice 22 is preferably machined in the wall ofthe deflector sub body 16 for receiving the nozzle 3 b 2. FIG. 6B is anenlarged view of orifice 22 in the wall of the deflector sub body 16.

FIG. 7 illustrates an alternative embodiment of the invention in whichdeflector sub 3 b is installed behind or uphole from a bit sub 13located at the end of tubular string 3. Bit sub 13 is preferably pluggedat its lower end 14 in order to allow fluid and pressure, in the drillstring or tubular string 3, to discharge through nozzle 3 b 2. The guidetubular 3 is illustrated as passing beside a bay brace 7 which resideson the exterior of the guide sleeve 15 through which the unusablewellbore is associated. The guide sleeve 15 is located on the lowermosthorizontal rig brace 1 d illustrated in FIG. 1.

In recovering a “slot”, a drill string or tubular string 3 is preferablylowered, through the “slot” to be recovered and at least some of itscorresponding vertically aligned guide sleeves 15, to a point aboutthree to four feet above the sea floor. It should be understood that thetarget depth can vary depending on several factors including, but notlimited to, the overall ocean depth, speed of currents, amount ofdesired deflection, and the size/weight of the guide string. Thus, itshould be appreciated that in more adverse conditions, the deflection ofthe tubular string 3 may need to be initiated earlier or later (i.e.further from or closer to the sea floor) in order to accomplish thedesired deflection or to avoid other objects such as, but not limitedto, other drill strings, or other drilling related operations. Theposition of tubular string 3 may then be verified with a measurementdevice such as a gyroscope. The tubular string 3 is then preferablydeflected by energizing a deflector sub 3 b which is preferably attachedto the end of the tubular string 3.

FIG. 8 illustrates tubular string 3 being deflected by the side thrust 3b 3 being produced by the fluid jet 3 b 1. FIG. 8 further illustrates anunuseable well bore 21 (the wellbore 21 being unuseable as describedherein above). The deflection, of the tubular string 3, preferablycauses the tubular string 3 to bypass at least the lower most guidesleeve 15 and an unusable wellbore 21 thus recovering the previouslyunuseable “slot” associated with its vertically aligned guide sleeve 15and unuseable wellbore 21. After tubular string 3 is deflected asillustrated, it is then preferably inserted or speared into the mud orsea floor B along line 3 c. It should be understood that line 3 c ispreferably deflected, at some desired angle, from a vertical axispassing through the recovered “slot” and its vertically aligned guidesleeves 15 and the unuseable wellbore 21.

After the tubular string 3 has been inserted or speared into the seafloor B mud line (FIG. 9), the pumping of seawater is preferably stoppedand measurements are taken to verify the position of the deflected drillstring or tubular string 3. The tubular string 3 may then be furtherlowered until it preferably supports its own weight axially. It shouldbe appreciated that the tubular string 3 will substantially sink throughthe mud or sediment bottom due to its own weight. It should beappreciated that as the drill pipe or tubular string 3 is loweredfurther into the seabed B, it will preferably retain its deflectedposition and not shift in a horizontal direction to its pre-deflectedvertically aligned position. The tubular string 3 may then bedisconnected at the rotary table (not illustrated) on the platform,leaving a stub protruding through the rotary floor (not illustrated).Another pipe or tubular string 2 (FIG. 9) may then be lowered over thedeflected tubular string 3.

FIG. 9 illustrates the drive pipe or tubular string 2 installed topreferably slide over the deflected tubular string 3. FIGS. 9, 10, 12,and 13 illustrate the tubular string 2 and the deflected tubular string3 being in a substantially concentric relationship. However, this isoptional since in order to maintain such a substantially concentricrelationship some type of centralization device (not illustrated), suchas a conventional tubular centralizer, would have to be used. Thedeflected tubular string 3 preferably acts as a guide string to deviatethe pipe string or tubular string 2 as it is lowered, over the deflectedtubular or tubular string 3, to the sea floor B. The pipe string ortubular string 2 will preferably be thrust into the mud below mud lineas illustrated in FIG. 10. The tubular string 3 may then be withdrawnfrom inside the pipe or tubular string 2, as shown in FIG. 11. It shouldbe appreciated that the conductor bay brace 7 may also aid in the offsetalignment of the drive pipe or tubular string 2. The conductor bay brace7 will preferably aid in preventing the drive pipe or tubular string 2from moving in a substantially horizontal direction toward the unuseablewell bore 21.

FIG. 12 illustrates an alternative embodiment similar to thatillustrated in FIG. 8 except that both the tubular string 3, with thedeflector sub 3 b, and pipe string 2 are installed/lowered together to adesired position above the seabed B. It should be understood that thetubular string 3 is installed/lowered while positioned in thethroughbore of the pipe string 2. As described herein above, pumps maybe activated to cause flow through the fluid jet 3 b 1 thus producing aside load 3 b 3 and deflecting both the tubular string 3 and tubularstring 2. When deflected, both the tubular string 3 and tubular string 2may be dropped/inserted into the mud to secure the deflected position.Further, as illustrated in FIG. 1, the inner tubular string 3 can beretrieved from the inner bore of the drive pipe or tubular string 2.

FIGS. 13-18 show another embodiment of a deflector sub 3 b. Thisembodiment will preferably allow the deflector sub to deflect thetubular string, as described herein above, and then redirect the jetflow from a side nozzle to a bottom nozzle or aperture to aid in theinsertion of the drill pipe or tubular string 3 into the seabed B or“glance” off other obstructions. FIG. 13 illustrates the nozzleswitching apparatus 23 which may be housed in a tubular section 8. Itshould be appreciated that the tubular section 8 may be attached to theend of tubular string 3, a pipe, or other tool or tubular as necessaryin a manner similar to that of the deflector sub 3 b described hereinabove. Preferably, the nozzle switching apparatus 23 comprises adrillable material such that the nozzle switching apparatus 23 will notrestrict further drilling operations. It should be appreciated that thenozzle switching apparatus 23 may be used as part of a guide string,wherein a larger tubular string is installed over it, or the apparatus23 may be utilized to guide and deflect the larger tubular. Stillreferring to FIG. 13, the nozzle switching apparatus further comprises aguide 8 b which is preferably configured to guide the piston 9. In itsfirst position, the piston 9 isolates the bore 8 a, of the tubularsection 8 from a lower cavity 12. The piston 9 preferably comprises aplurality of grooves 9 c, disposed about the piston 9, which may engagecorresponding ridges 8 d, disposed about the inner circumference of thelower portion of the tubular section 8. The engagement of the ridges 8 dwith the grooves 9 c will preferably prevent rotation of the piston 9when it is necessary to drill out the nozzle switching apparatus 23 (SeeFIGS. 16-18). The lower most portion of the tubular section 8 preferablycomprises an end 8 c preferably having an opening 8 f, which may becircular or non-circular, as desired.

The piston 9 is preferably configured with a central channel 9 a boredin a substantially longitudinal direction to intersect with a cross bore9 b which passes through the piston 9 in a substantially radialdirection. In the first position, the piston 9 is releasably securedsuch that the cross bore 9 b is in fluid communication with a nozzle 8e. It should be understood that the piston 9 may be held in the firstposition by a variety of attachment means including, but not limited toshear screws, set screws, ridges, frangible supports, pins, rivets,screws, bolts, specific tolerance fits or a variety of otherconventional retention means.

As with the deflector sub 3 b, preferably a fluid, such as seawater, ispumped into the nozzle switching apparatus 23 to activate the jet flowJ1 by pumping or propelling the fluid through the nozzle 8 e. It shouldbe understood that the fluid is pumped through the pipe or tubularstring which extends from the tubular section 8 to the drilling rig orother drilling structure. As the fluid is pumped through the bore 8 a ofthe tubular section 8, it will preferably enter the central channel 9 a,move into the cross bore 9 b, and be exhausted through the nozzle 8 e toproduce the jet J1. The jet J1 will preferably produce a thrust force ina similar manner to the jet 3 b 1 thus causing the tubular 8 and anyattached tubular string to deflect in a direction substantially oppositethe nozzle 8 e.

When the desired deflection is achieved and/or it is desired to switchoperation from the side nozzle 8 e to the bottom nozzle or aperture 8 f,a ball 10 or other stopper is preferably dropped down the bore of thetubular, attached to the tubular section 8, to close channel 9 a asillustrated in FIG. 14. With the seawater still being pumped into thebore 8 a, the pressure builds up against the top of piston 9 andpreferably forces the piston 9 downward to a second position asillustrated in FIG. 15. It should be appreciated that the pressureincrease, which preferably occurs due to the ball or stopper 10 blockingchannel 9 a, will shear or break any support maintaining the piston 9 inits initial position and thus allowing for its downward travel. Afterthe piston 9 moves from the first position, cross bore 9 b will nolonger communicate with the nozzle 8 e. In the second position, crossbore 9 b will preferably open to the cavity 12.

After the piston 9 has moved to the second position, the pressure inbore 8 a is further raised to pump the ball 10 through the centralchannel 9 a and the cross bore 9 b to permit flow through the bottomhole 8 f. It should be understood that ball 10 may be comprised of avariety of materials 4 ncluding, but not limited to, elastomeric,plastic, or frangible materials such as to allow the ball 10 to deformor break in order to pass through the central channel 9 a, the crossbore 9 b, and into the lower cavity 12. After the ball 10 is pushed outof the piston 9, as illustrated in FIG. 16, any flow though the bore 8 ais preferably directed through the bottom hole 8 f to aid in reducinginterference from mud and sediment which is preferably loosened orremoved by the flow through the bottom hole 8 f. It should beappreciated that the bottom hole 8 f can also be configured to accept anozzle, such as 8 e or 3 b 1 to produce a more forceful jet flow forreducing the interference.

FIG. 17 illustrates an embodiment wherein the interior components of thetubular section 8 and the attached tubular string are ready to bedrilled out for subsequent activity. A milling or drilling assembly 11,which may be commonly run on a drill string, includes at least onecutter insert 11 a. It should be understood, by those in the art, that aconventional milling or drilling assembly 11 will preferably drill ormill out substantially all material attached to the inside diameter oftubular 8. FIG. 18 illustrates the pipe string or tubular 8 after thedrilling operation has been carried out. Typically, the side nozzle 8 ecan remain unplugged.

Referring now to FIGS. 19 and 20, the lowermost end of the drive pipe ortubular string 2 will preferably, comprise a drive shoe 26 which may beintegral to the lowermost section of the drive pipe or tubular string 2or may be a separate drive shoe attached to the lowermost section of thedrive pipe or tubular string 2. It should be appreciated that theattachment of the drive shoe 26 is well know in the art and will not bedescribed in detail herein. It should be understood, that although theembodiments illustrated herein show the lower most end of the tubularstring 2 as having an angular shaped end, the shape should not be viewedas limiting. A variety of other end configurations should be includedwithin the scope of this invention as the end serves to allow easierentry into the seabed B and aid in guiding the tubular string 2 pastobstructions as it is lowered from the rig to the seabed B.

As illustrated in FIG. 19, an embodiment of the drive-shoe 26 maycomprise a miter cut 28, a solid bottom end 35, and a hole 34 offsetfrom the longitudinal centerline of the shoe 26. The solid bottom 35 maybe a plug, a cap, a molded cap, a welded end, or other desirable closuremember. Preferably, solid bottom 35 will be of an easy drillable,frangible, or otherwise removable material, for example, high densitypolyethylene. The hole 34 allows the deflector sub 3 b, and any attachedtubulars to pass through as the larger diameter tubular 2 is loweredover the drill string or tubular string 3. The miter cut 28 preferablypermits the conductor pipe 2 to “glance” off and not become hung up onthe conductor bay brace 7 (see for example FIGS. 8 and 9), other tubularstrings, or other drilling and production equipment should it come incontact with them. It should be appreciated that when the drive shoe 26initially contacts the conductor bay brace 7, other tubular strings, orother drilling and production equipment there will be a point forceexerted on the drive shoe 26 from the contact. The hole 34 is preferablyprovided so that the position of the conductor or tubular string 2 withrespect to the drill pipe or tubular string 3 can be controlled.Preferably, the drive-shoe 26 on the conductor pipe or tubular string 2will effectively “ramp” off the conductor bay brace 7 with littleresistance and allow the tubular string 2 to enter the seabed B.

As further illustrated in FIG. 19, an embodiment of the drive shoe joint26 preferably comprises a miter cut 28 with reinforcing material 30 onthe long end to prevent curling of the tip 32. The remainder of thedrive shoe is preferably manufactured from steel or anothernon-drillable material. The miter cut 28 may comprise various anglesdepending on factors such as, but not limited to, spacing of other guidesleeves 15 (FIG. 1), other drilling strings, casing, tubing, tooljoints, tubulars, and other drilling related operations.

It should be understood that the drive shoe 26, with the miter cut 28,may also be utilized to avoid collisions with other tubular strings in amanner similar to the “glancing” effect described herein above. Further,the combination of the drive shoe 26, with the miter cut 28, and theguide string 3, similar to the embodiment illustrated in FIG. 12, may beutilized to avoid collisions by activating the fluid jet 3 b 1 inconjunction with the miter cut 28 “glancing” operation. It should alsobe appreciated, that when desired, fluid may also be moved through thebore of the shoe 26 such that the fluid, when exiting through the hole34 may aid in moving the drive shoe through the softer sediment and mud.

Referring now to FIG. 20, there is illustrated the lower end of aconductor pipe 200 having an end 202 having at least one nozzle 204located in the side wall 206 of the conductor pipe 200. In the operationof the conductor pipe 200, fluid flowing through the nozzle 204 willcause conductor pipe 200 to be thrust in the direction of the arrow 208.With this embodiment, by putting the nozzle in the conductor pipedirectly, there is no requirement of using a drill string and thenlowering the conductor pipe over the drill string. In this embodiment,the conductor pipe is directly deflected.

As an option, the lower end of the conductor pipe 200 can be filled withan easy drillable material 210, for example, hard plastic.

Referring now to FIG. 21, an alternative embodiment of the invention,which illustrates the use of a plurality of nozzles in the side wall ofa tubular, for example, nozzles 220 and 230 which generate a resultingthrust along the dotted line 240 indicative of the vector sum of themultiple thrusts which result in a deflection of the tubular along thearrow 215.

Operation

In practicing the present invention, in order to recover the use of anexisting slot which has formerly been used in an abandoned wellbore, theexisting string or strings of pipe have to first be removed.

All uncemented strings of pipe, if not stuck within the wellbore, arepulled from the abandoned wellbore, and usually also any pipes remainingbetween the seabed and the slot to be recovered.

Any remaining strings of pipe are cut approximately eighty feet belowthe mudline by conventional apparatus and methods which are well knownin the art of cutting tubulars such as casing cutters, production tubingcutters, drill pipe cutters, and the like. Such well-known tubularcutting technology includes the use of mechanical cutters, explosivecutters, chemical cutters, and combinations thereof.

After the existing strings of pipe have been removed, new strings ofpipe are run through the recovered slot and then through the verticallyspaced braces such as the guide sleeves 15 used with the braces 1 a-1 ddiscussed herein with respect to FIG. 1. The new string or strings arethen run down to or into the mudline and the string or strings can thenbe moved laterally by the various fluid jetting processes hereindescribed.

From the foregoing, it will be seen that this invention is one welladapted to attain all of the ends and objects hereinabove set forth,together with other advantages which are obvious and which are inherentto the tubular string deflector and method of the present invention.

The tubular string deflector and method of the present invention andmany of its intended advantages will be understood from the foregoingdescription. It will be apparent that, although the invention and itsadvantages have been described in detail, various changes,substitutions, and alterations may be made in the manner, procedure anddetails thereof without departing from the spirit and scope of theinvention. It should be understood that certain features andsub-combinations are of utility and may be employed without reference toother features and sub-combinations. This is contemplated by and iswithin the scope of the claims.

1. A drive shoe configured for fixedly attaching to an end of a tubularcomprising: a first end configured for fixedly attaching to a firsttubular; a second end, wherein the second end defines a first aperturethrough which a second tubular may pass while the first tubular isslidably inserted over the second tubular, wherein the drive shoe mayguide the first tubular as it is slidably inserted over the secondtubular, said drive shoe having an outer wall.
 2. The drive shoe ofclaim 1, wherein the second end is configured having an angular shape.3. The drive shoe of claim 2, wherein the angled second end allows thedrive shoe to be lowered past obstructions without substantialhindrance.
 4. The drive shoe of claim 1, further comprising a solidmaterial disposed about the second end, wherein said solid materialdefines the first aperture.
 5. The drive shoe of claim 1, wherein thesolid material is a composite material.
 6. The drive shoe of claim 1,further comprising a reinforcement disposed about the second end,wherein the reinforcement substantially prevents deformation to thesecond end.
 7. The drive shoe of claim 1, defining at least a secondaperture in said outer wall of said drive shoe.
 8. The drive shoe ofclaim 7, wherein at least one nozzle is mounted within said at least oneaperture, respectively.
 9. An apparatus for deflecting a tubular havinga tubular wall and a bore therethrough, comprising: At least one nozzlemounted within at least one aperture, respectively, in the tubular wallwherein fluid moving through the tubular bore is directed through saidat least one nozzle, and wherein said fluid moving through said at leastone nozzle creates one or more jet flows which deflect the tubular in adirection substantially opposite from the vector sum of the thrustsgenerated by the fluid flow through said at least one nozzle.
 10. Anapparatus for deflecting a tubular conductor pipe having a tubular walland a bore therethrough, comprising: a nozzle mounted within an aperturein the tubular wall of said conductor pipe, wherein fluid moving throughthe tubular bore is directed through said nozzle, and fluid movingthrough said nozzle creates a jet flow which deflects the tubularconductor pipe in a direction substantially opposite the direction offluid flow through said nozzle.